Oil Well Improvement System - Pressure Relief, Diversion Capture &amp; Recovery

ABSTRACT

The parent patent—The Oil Well Improvement System—incorporates and integrates several different unique assemblies and subsystems that provides a cost effective disaster preventive system for offshore oil wells while concurrently providing the means to reduce the cost of the drilling processes. 
     The system modifies the sea-floor, in-well and platform equipment and processes. 
     This divisional patent—The Pressure Relief, Diversion Capture &amp; Recovery Subsystem—acts in concert with the Oil Well Improvement System to provide an additional and/or interim means to control a blown out well by providing an alternate/safe low resistance flow path along with the means to capture and recovery oils/gases.

CROSS-REFERENCE TO RELATED APPLICATIONS

The present utility patent application claims the benefit of provisionalapplication No. 61/459,895 filed Dec. 20, 2010.

STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH OR DEVELOPMENT NotApplicable. THE NAMES OF THE PARTIES TO A JOINT RESEARCH OR DEVELOPMENT

Not Applicable.

BACKGROUND OF THE INVENTION

Field of the Invention

The present invention relates to disaster prevention system for offshoreoil wells and in particular to a supplemental disaster preventive systemto provide means to insure human, equipment and environmental safety andassociated cost avoidance during the offshore well drilling processunder all conceived/feasible accidents/failures conditions. The overallsystem design concept, related procedures/processes and many associatedsystem components to provide major cost reduction benefits for theentire life cycle (drilling, completion, production and abandonment) forboth accident/failure and normal/uneventful operations.

Description of Related Art Including Information Disclosed Under 37 CFR1.97 and 1.98 Shortly after the 2010 offshore oil well catastrophe inthe Gulf of Mexico, it became obvious that British Petroleum (BP), theentire oil industry, and/or the US Government were unprepared toeffectively stop the gushing oil or the means to clean it up. Throughoutthe first two plus months of the disaster numerous re-sealing,capturing, clogging, killing and capping techniques were unsuccessfullyattempted and several high risk/cost ‘normal’ well drilling processeswere brought to light.

The successful 20 July re-seal, capture and cap ‘Rube Goldberg’/‘Kluge’(said with admiration) was a simplistic but effective temporary solutionfor the catastrophic symptoms of the problem—where the primary operativephrase is ‘temporary solution for the catastrophic symptoms’.

The enormous somewhat/sometimes unquantifiable costs of the (or of afuture) incident includes:

Human life,

Environment,

Drilling platform,

Well (the equipment and the associated labor and its potentialproduction),

Equipment and labor associated with the numerous re-seal, capture, andcap ‘quick fixes’,

Equipment and labor associated with the relief/kill wells,

Gulf clean-up,

Tourist and fishing industry,

Local community,

Public opinion relating to the oil industry & the government and

Nation and international financial markets

The prior art ‘blowout prevender’ (BOP) is intended to close off thewell in case of an uncontrolled/emergency condition (blowout). It's amulti mega-buck, multi-ton device installed on the seafloor havingvarious means/methods, with the design intent of closing a well. Themost technically difficult is if/when a pipe and/or pipes (drill,casing, etc.) are within the well. The BOP must ‘ram’ through thepipe(s) and close off the well. That seems difficult, but add theextreme water pressure and low temperatures, the more extreme oilpressure and high temperatures and the prior art BOP is likely not goingto work. After the Macondo's well was finally closed, the BOP was pulledup and evaluated—it was functional but did not do the job.

As offshore oil drilling/production continues in the future it seemsonly rational that the government as well as oil industry itself woulddemand, as a prime priority the development of improvedequipment/systems and processes.

Whatever the cause(s) (human neglect/error, equipment failure, etc.) ofthe 2010 oil well disaster and whatever means are developed to insure nosuch similar failure and/or related impacts reoccurs, there arepotentially more likely and more damaging events—specifically naturaldisasters and (accidental or deliberate) human intervention that mustalso be addressed.

The focus of the ‘quick fix’ was to stop/control the symptoms of theimmediate catastrophe—the gushing oil.

What is needed is an overall systems design and implementation approachthat provides the means to reduce/eliminate the causes and impacts ofany conceived/realistic threats to oil wells in the future and furtherprovides more reliable, practical and cost effective means to accomplishthe oil well drilling task.

BRIEF SUMMARY OF THE INVENTION

The primary design objective of the present invention was to provide anoffshore oil well improvement system using an overall systems design andimplementation approach that provides the means to reduce/eliminate thecauses and impacts of any conceived/realistic threats to oil wells inthe future and further provide more reliable, practical and costeffective means to accomplish oil well drilling.

As the present invention design evolved it became apparent that manyrelated procedures/processes and many associated system componentsprovide major cost reduction benefits for the oil well's entire lifecycle (drilling, completion, production and abandonment) in eitherproblem or normal operations.

The present invention is composed of two functional and physicallyintegrated subsystems, the Multi-Function Well Subsystem (MFWS) and theIntrusion Detection and Response Subsystem (ID&RS).

The MFWS is presented in two basic configurations, the ‘Fundamental’ &the ‘Advanced’. Both configurations modify the sea-floor and in-wellequipment to provide maintenance access and unique tools to provide themeans to: cap the well, seal/re-seal the well, drill/re-drill the well,kill the well from the top, improve BOP reliability, add BOP functionalredundancy, improve the cementing process, incorporate a sea-floorpressure relief/diversion function and improves the well's life cyclesafety.

The Advanced MFWS includes a unique dome top cylindrical sidewallstructure enclosing the well's sea-floor equipment providing improvedstructural strength as well as passive protection from natural/humaninduced disasters.

The ID&RS provides the means to detect, track and classify the 3Daspects of air/surface/sub-surface objects about a specific oil well orgroup of oil wells and provides the means to evaluate and eliminatethreats.

As all elements are based on existing simplistic proven technology, thedevelopment cost risk is minimum.

As the system design includes a major focus on the physicalimplementation and operation, the implementation and operational costrisk is minimum

Considering the pure human and environmental safety, the pure dollar andcents (or multi-million/billion dollar) cost avoidance and/or thepotential cost savings/reductions (for any or all such reasons) it is asignificant understatement to suggest that features of the presentinvention should be integrated with other planned improvements, andincorporated on all oil wells.

BRIEF DESCRIPTION OF THE SEVERAL VIEWS OF THE DRAWINGS

These and other details of the present invention will be described inconnection with the accompanying drawings, which are furnished only byway of illustration and not in limitation of the invention.

The drawings are intended to provide an introductory overview of majorsystem/system elements that along with other unique system supportingdevices are comprehensively defined in the ‘Detailed Description Of TheInvention’.

FIG. 1 is a diagrammatic cross-sectional view of the FundamentalMulti-Function Well Subsystem (MFWS) showing a typical oil well'ssea-floor equipment of a Stud (3), Marine Riser (4), BOP (5), ProductionValve Assembly (6) and Well Pipe/Casing (2) sitting on the Sea-Floor(1). Connected to this ‘typical’ equipment is a ‘Normal’ Capture Valve &Associated pipe (11) going to a surface capture platform and a welldrill & return pipe (9) ‘typically connected to (6) going to a surfacedrilling platform. The drawing further depicts the addition of twoadditional items, an Adjunctive BOP/Valve Assembly (AVA) (7) and aPlatform to Well Interface Assembly (P-WIA) (8) in series with the‘typical’ well's interface of (6) & (9). These two units are furthershown on FIGS. 3A & 3B and FIG. 4. These units provide functionalredundancy of the BOP (using alternative, simplistic technology) toseal/close the well. Unit (8) provides the means to seal the drillpipe's exterior wall return flow path while unit (7) closes the entirewell's flow path when there no obstruction (drill pipes, casings etc.)within the valve area of unit (7). Note the drawing does not depict thedrill pipe, drill bit or various casings that may be going into the wellfrom the drill platform during the drilling stage. When in use thesewould be feed through items (9, 8, 7, 6, 5, 4, 3 & 2). It is furthernoted that the full ‘functional redundancy of the BOP’ is not yetcomplete in that the BOP can (by intent but with poor reliability) ramthrough an obstruction and close the well. The full ‘functionalredundancy’ is provided by one of two alternate means. The first is theEnclosed Pipe Cutter within (7) and the second is the remote PipeCoupling/De-Coupling device as shown on FIG. 6. In either case the cutor de-coupled pipe must be extracted from the valve area of unit (7).Such would be accomplished via the drill platform or a Remote OperatedVehicle (ROV) lifting the pipe/casing or the addition of an internalpipe lifting device (not shown). FIG. 1 further shows a PressureRelief/Diversion Valve & Pipe/Tube (10) on a parallel well output portof unit 6. This provides an input to the Pressure Relief/DiversionAssemble as shown on FIG. 5. This provides the means to safely protect aproblem well & platform, the means to safely capture the well output andthe means to safely reduce/eliminate the disastrous effects on theenvironment.

FIG. 2 is a diagrammatic cross-sectional view of the AdvancedMulti-Function Well Subsystem (MFWS) in a similar fashion to FIG. 1.FIG. 1 begins showing a ‘typical’ oil well's sea-floor equipment of aStud (3), Marine Riser (4), BOP (5) & Sea-Floor (1) (as identified onFIGS. 1 as 1,2, 3, 4, & 5).

The Advanced MFWS differs by replacement the Production Valve Assemblywith a unique manifold Domed Assembly (DA) structurallyenclosing—reinforcing the well's sea-floor equipment. The DA consists ofa Dome Cylindrical Sidewall (21), a Dome Top (22), and the Dome InteriorPlate (23). The DA's lower section further includes Leveling Devices(24), Floor/Footing (25), & Vent Pipes (26). The Dome Top (22) includesparallel well outputs for the Normal Capture Valve & Pipe (11) & thePressure Relief/Diversion Valve & Pipe (10) (functionally identical to11 & 10 on FIG. 1). The DA upper section further includes a large ROVAccess Port (27) that can be converted to the smaller port size of anormal BOP feed thru access by installing the Access Port Adaptor (APA)(28). Two sets of AVA's (8) & P-WIA' s (7) are provided in series withthe Normal Well Drill & Return Pipe (9). One set is connected to the BPO(5) via the BOP Output Adaptor (OPA) (32) and a Pipe Mounting Adaptor(PMA) (31). The other set is connected to the APA (28). The DomeInterior Plate (23) includes a Cable/Tube Access Hole and an associatedCable/Hole Sealer (29) (further shown on FIG. 3A). The interior areabetween the Dome Top (22) & Dome Interior Plate (23) and furtherenclosed by 28, 29, 31, 32, 10 & 11 is the Reservoir Area (30) sealedform the exterior sea water and is capable of holding well pressure.

FIG. 3A is a diagrammatic cross-sectional view of the AdjunctiveBOP/Access Valve Assembly (AVA)-Housing with an Enclosed Pipe Cutter(EPC).

The Housing (41) includes a physical area (42) below the Access Valve(43) that incorporates the EPC. The mechanical aspects of the EPC areshown on FIG. 3B. As a general reference the BOP Access Area (44) isshown as dashed lines. As a specific reference to the Advanced MFWSrelating to the lower (ref. FIG. 2) AVA (7) & P-WIA (8), the DomeInterior Plate (23), PMA (31), OPA (32), Cable/Tube Access Hole &associated sealer (29) and AVA, P-WIA & DA control & monitorcables/tubes (45) are shown. In the case of the Fundamental MFWS the AVA(7) is directly connected to the Production Valve Assembly (6) and theupper set of AVA (7) & P-WIA (8) of the Advanced MFWS directly connectsto the APA (28) (ref. FIG. 2).

FIG. 3B is diagrammatic cross-sectional top view, at the EPC elevationdepicting the mechanical aspects of the Adjunctive BOP/Access ValveAssembly (AVA) with EPC. Item 51 is a flat circular/donut shapedturn-table connected to the AVA housing via ball bearings. Item 52 (indashed lines) reference the BOP's access area depicting the requiredcentered opening of item 51. Item 53 is the turn-table motor assemblyconsisting of a motor, gearing, encoder & associated housing. The motorhousing is attached to the AVA housing. The motor shaft, gearing &encoder interface with the turn-table. An item 54 (in dashed lines)represents the AVA housing under the turn-table.

Item 55′s are six Lateral Drive Devices.

Items 56 are three circular saw blades each including a motor &tachometer. Items 57 are three wedges. Items 58 & 59 are details ofitems 55. Item 58 is the fixed member of item 55. It is affixed to theturn-table and includes a lateral drive motor, an encoder, slides &gearing. Item 59 is the lateral sliding member of item 55 and includesslides & gearing. The dashed lines at item 59 indicate this member atits extended position.

FIG. 4 is a diagrammatic cross-sectional view of the Platform to WellInterface Assembly (P-WIA).

Item 61 depicts the housing. Item 62 depicts the return flowopening/path. Item 63 is the remotely controlled by-pass valve allowing(return) flow around a sealed pipe outer wall to return. Items 64 areremotely controlled expandable ‘o’ ring gaskets capable of closing thearea between the interior pipes outer sidewall and the AVA's housing(the return path). The dashed lines at items 64 show the said gasketexpanded. Item 65 is a sample pipe within the P-WIA. Item 66 is areference to the Normal Well Return Pipe going to the drill platform.This reference is applicable to the Fundamental MFWS & the upper P-WIAof the Advanced MFWS. The lower P-WIA of the Advanced MFWS is opened tothe Reservoir. Item 67 (in dashed lines) is a reference to the BOP'saccess feed-thru area. FIG. 5 is a diagrammatic cross-sectional view ofthe Pressure Relief/Diversion Assembly. Item 71 is theContainment/Separator Tank. Although not shown it is assumed internalelements would provide enhanced oil-water-mud-gas separation beyond thatobtained by a simplistic internally opened tank. Item 72 is the Ballastrequired to stabilize the tank to the Sea-Floor (1) as the tank takes ondifferent elements (initially filled with sea water and latter replacedwith mud, oil & gas). Items 10 & 11 are references to the PressureRelief/Diversion Valve and the pipe/tubing coming from the well as seenon FIGS. 1 & 2. This pipe/tube extends horizontal from the well'ssea-floor equipment to a safe area where any possible release of oil/gasfrom the well will not impact the safety of the surface equipment orpersonnel. Item 73 is a composite of numerous controls and internal tankmonitoring/sensors interfacing with the surface equipment. Items 77 arepipes/tubes to further divert and/or capture the tank's separatedholdings. It is assumed the different separated outputs would go todifferent places (such as oil to a surface containment area or capturevehicle while the gas may be diverted to a further safer area fatheraway from the oil containment/capture area). Items 74, 75 & 76 areremotely controlled valves. Item 74 is the Sea Water/Mud Valve and wouldinitially be opened in conjunction with the Pressure Relief/DiversionValve to allow the tank to extract its initial sea water and accept thewells output. As sensors indicate the tank no longer contains seawater/mud the valve would be closed. Item 75 is the Gas Valve. If gas issensed within the tank this valve would be opened. Item 76 is the OilRelease Valve. As oil is sensed within the tank this valve would beopened.

FIG. 6 is diagrammatic perspective & cross-sectional views of amatching/mating pair of the Coupling/De-Coupling Pipes.

Items 81 are the upper end & lower end of the upper & lower couplingpipes. These ends have standard pipe to pipe coupling means. Item 82 (indashed lines) indicates the inside wall. Item 84 is the smaller diameterupper pipe coupling surface that fits within the lower coupling pipe asindicated by the dashed lines of Item (90). Item 89 depicts a taperedthe bottom portion of item 84 allowing it to initially align/fit intothe lower section. Item 83 is the upper pipe's mounting flange & gasketthat mates to the lower pipes mounting flange item 91. Item 92 is aunique threaded element in the interior sidewall of the lower pipe. The‘unique’ threads have a stepping characteristic as shown on Detail ‘B’item 93. The widths of the individual steps are slightly larger than thewidth of the remote controlled Spring Loaded Grabbing Device (SLGD),item 85. Items 85 are installed on the upper coupling pipe via Pivots(87) and normally extend out from the sidewall via its internal spring.When compressed the SLGD fits into the pipe's sidewall per item 88.Detail ‘A’, item 94 indicates a sloped mating (mating the slope of item93) of the SLGP. As the upper & lower sections are joined the SLGDscompress into the sidewall and springs in & out of the different levelsof the stepped threaded element. When the mounting flanges bottom-outthe upper pipe is turned clockwise (where it ratchet into, furthertightens and locks into the threaded-stepped element. The pipesde-couple via energizing the SLGD remote control mechanism, item 86where the SLGD is pulled into its sidewall unlatching/freeing the twopipe sections.

DETAILED DESCRIPTION OF THE INVENTION

The system of the present invention comprises two functional andphysically integrated subsystems, the Multi-Function Well Subsystem(MFWS) and the Intrusion Detection and Response Subsystem (ID&RS).

Both MFWS configurations (Fundamental and Advanced) utilize ‘other’ (notshown on Figures) unique support devices including: Production Hard Cap(PHC) Remote Monitor and Control Unit (RM&CU) Re-Case End Pipe (R-CEP)Re-Case Pipe (R-CP) Bottom Kill End Pipe (BKEP) Kill Pipe (KP) ModifiedConversion Float Valve (MCFV) Modified Casing (MC) Modified ReamerShoe/Drill Shaft (MRS/DS) Modified Drill Bit (MDB)

The Production Hard Cap (PHC) is a simplistic device. It is round asviewed from the top and has a mounting surface compatible with both theProduction Valves and the Production Ports. The PHC is utilized toprovide means to cap each individual unused Production Port and/orValve.

The Remote Monitor and Control Unit (RM&CU) is a platform mountedspecialized device associated with the Multi-Function Well Subsystem(MFWS).

The RM&CU will provide the surface platform to sea-floor and in-wellequipment man-machine monitor & control interface. The RM&CU willinclude processing capability to provide operator recommendations andwarnings, as well as an automatic mode to control the sea-floor andin-well equipment for critical/emergency situations. Although specificoperational displays, modes, functions or controls are not specified indetail at this time, it is assumed the RM&CU equipment (such asmonitors, computers and interface devices) matching/exceeding the systemrequirements are commercially/off-the-shelf available. The Re-Case EndPipe (R-CEP) is a pipe section smaller in diameter than the installedwell pipe/casing in need of repair when the drill pipe is not in thewell. It will have a remotely controlled initially closed bottom endvalve, a remotely controlled expandable ‘o-ring’/gasket around its outercircumference near the closed end. It will further have a remotelycontrolled sidewall gate valve located slightly above the said gasket.Prior to installing the R-CEP the number of sections of Re-Casing Pipe(R-CP) required to repair the well must be determined. At a point abovewhere the existing well pipe is in need of repair but below the BOP, apair of remotely controlled Coupling/De-Coupling Pipes shall be joined,followed by additional sections of R-CP from above the bottom of the BPOto the surface platform. The R-CEP and R-CP would be lowered through the‘normal outer/return drill pipe’ to the desired location. The R-CEPgasket would be energized sealing/closing/choking the pipe to pipe area.The sidewall remotely controlled gate valve will be opened and mudfollowed by concrete would be pumped directly into the re-casing pipe.The mud/concrete flows through the opened gate valve and into thepipe/casing in need of repair to seal the pipe to pipe/casing area. Theconcrete will flow through said area until cement is detected in thepipe to pipe area above the last (highest) section of well pipe thatneeded repair. The concrete pumping will stop, the sidewall gate valvewill be closed and the concrete will be removed from the interior of theRe-Case Pipe. The bottom remotely controlled closed end valve will thenbe opened. The concrete is let to set between the pipe to pipe areas.The Re-Case Pipe (below the BOP and above the well pipe that requirerepair) will be uncoupled via the Coupling/De-Coupling Pipe (or will becut and extracted).

The Re-Case Pipe (R-CP) is similar to the lowest section of theinstalled faulty well pipe/casing except: [0051] Smaller in diameter.Selected sections (the uppermost as a minimum) shall incorporateremotely monitored exterior pressure, oil, water, mud and concretesensors.

The Bottom Kill End Pipe (BKEP) is similar to the R-CEP except: The‘initially’ closed bottom end will also have a permanently closedsection above it. The volume between the initially and permanentlyclosed portions will contain pre-loaded ‘junk’, along with a remotelycontrolled means to open the bottom and release the ‘junk’. The ‘junk’will be of various size material, flexible, buoyant (in oil) and capableof withstanding well pressures and temperatures, will not include theremotely controlled circular hydraulic controlled gasket around itsouter circumference near the closed end, but instead will include alarge expandable remotely controlled end plug (similar to an expandablepipe plug). The ‘large’ plug will be capable of expanding to thediameter of the well bore. The large plug will be set below the wellcasing and the plug would be expanded. The initially closed bottom endwill be opened releasing the junk further sealing/clogging/choking thewell. Mud followed by concrete would be pumped through KP in a similarmanner as the Re-Case Pipe except the concrete will also flow into thewell bore and the concrete will not be evacuated from the pipesinterior. The upper sections of pipe will be removed in a similar manneras the Re-Case Pipe.

The Kill Pipe (KP) is similar to the R-CP except the ‘selectedsections’(the uppermost as a minimum) shall incorporate remotelymonitored interior (as well as exterior) pressure, oil, water, mud andcement sensors.

The Modified Conversion Float Valve (MCFV) changes the releasemethod/mechanism from the present dropped ball, semi obstructing theflow through a pipe holding the valve opened causing a delta pressure.When/if the delta pressure and flow meet a pre-selected criterion, thesaid pipe releases and converts the device to a one-way valve.

The modification converts the valve to an electrical remote controlleddevice—activating a solenoid. The opening valve will further be springloaded and its opening will be sensed and reported and remotelymonitored as flow-rate.

The Modified Casing (MC) incorporates remote controlled sidewall gatevalves near the top of the casing. Although the MC is primarily intendedfor the lower most casing, it could be desirable for other casingsections as well. The said valves would be initially being held closed.Upon command the valves will allow one-way flow, from the pipe into thewell-bore. This will allow cementing from the top of the casing to thebottom, reducing the required pressure and further provides a morepositive void/bore fill.

The Modified Reamer Shoe/Drill Shaft (MRS/DS) modifications combine thefunctional elements of the R-CEP and the BKEP with the followingalterations: The ‘large’ ‘plug’ element of the BKEP is incorporated onthe lower part of the shaft/collar slightly above the shoe or drill bitto seal/clog/choke the well bore to drill shaft/collar incorporates aremotely controlled gate valve device internal to the pipe, just abovethe drill bit to restrict flow through the drill bit. The remotelycontrolled ‘o-ring’ pipe to pipe sealing gasket around the pipescircumference incorporated on the R-CEP shall be re-located to above thecontrolled gate valve. The intent of the MRS/DS is: Similar to the BKEPby providing the means to kill the well below the last pipe in the wellbore, but with the reamer/drill shaft in the well. Similar to the R-CEPby providing reliable means to re-case (specifically the pipe to pipecementing process), but with the drill shaft/collar and/or the ReamerShoe in the well to provide improved reliable means to cement the lastpipe to the well bore.

The ‘Fundamental’ MFWS provides maintenance access, redundancy,sea-floor pressure relief/diversion means and utilizing common uniqueand in-use apparatus and tools, used in conjunction with a newly devisedoil well access to provide the means to: Cap the well, Seal/re-seal thewell, Drill/re-drill the well, Kill the well (at the bottom from thetop), Improve BOP(s) reliability and Improve means to end casing

The ‘Advanced’ MFWS includes all the features of the above, and furtherincludes a unique dome top, cylindrical sidewall assembly/structureenclosing the well's sea-floor equipment providing improved structuralstrength and protection from natural/human induced disasters.

Either the Fundamental or Advanced MFWS configurations could be modifiedto include an additional Adjunctive BOP/Access Valve Assembly (AVA)installed below the BOP providing further redundancy.

MFWS Detail Design Notes/Information

The dome's size is determined by the wells characteristics. The primaryfactor is the height of the wells above sea-floor equipment (MarineRiser and BOP and newly installed adaptors/assemblies—OPA, PMA, and AVAand P-WIA) followed by the margin of safety associated with the: lateralstability of the DA (diameter to height ratio), sidewall strength beyondthat required to support the top members—where the ‘beyond’ is thestrength to compensate for falling objects/underwater blasts, height andwidth of the required maintenance area (ROV workspace). The overall‘Dome Assembly’ size shall be as small as possible but its sidewallheight shall be greater than the existing wells sea-floor equipment(Marine Riser and BOP)—(generic/ball-park height >60′). The sidewalldiameter will provide lateral stability of the Dome Assembly and have asurface area compatible with all required dome top ports. (>two thirdthe height, generic/ball-park diameter >40′) The initial (pre-cementing)weight of the Dome Assembly shall be slightly greater than the weight tosink it to the sea-floor, But if prior to its installation, the wellhead is opened and under pressure and can not be controlled/stopped,then weight must be added to overcome the well pressure. The addedweight shall be determined assuming all top ports/valves opened (thesaid ports/valves would be opened during the normal installation/settingprocess). The top domed member (dome top and interior plate forming thereservoir) shall be made of material and joined in a manner to withstandgreater than two times the wells' anticipated pressure. The cylindricalsidewall of the dome is fabricated with material and supporting bracescapable of supporting the top (domed) structure and act as a concreteform to structurally connect the dome top section to a concrete floorpad. The center interior will include installation positioning/guidebraces about the locations of Marine Riser, BOP and BOP Output PipeAdaptor. The sidewall may be made of two or more vertical separablesections enabling sea-floor equipment changes for thecompletion-production phases (if/as desired). The exterior of thesidewalls will include a minimum of three horizontally extending ‘L’brackets. The brackets will support remotely controlled leveling jackscapable of lifting/leveling the pre cemented Dome Assembly. The dome topto sidewall mechanical interface shall include lifting hooks/eye-boltsand shall be capable of supporting the DA's initial (pre-cemented)weight. After the DA is set (positioned and leveled) on the sea-floor,pressure relief vent pipes (approximately 3-4 feet long) will bevertically set in the sea-floor having the vent pipes be semi-evenlyspaced in the floor and encompassing an area approximately five percentof the total sea-floor area, and a concrete floor (approximately 3 feetdeep) will be poured (structurally connecting the Well Stud to thesidewall). The cylindrical sidewall will include an opening the sizecompatible with passing through a ‘typical’ off-shore oil well's ROV.The opening will be enclosed by a door. The door will include pressurerelief/venting means allowing higher internal pressure to be released,while sealing the interior from higher external pressure. The center ofthe dome top will house a large access port. ‘Large’ is defined as thearea capable of passing through a device the size of an ROV. The portwill be initially used to access the interior of the dome duringinstallation and latter for repair/replacement on assemblies within thedome. The exterior of this port area will include guide-pins and boltstuds to mechanically secure an Access Port Adaptor (APA). The APAreduces the port size and is used to connect various assemblies/adaptorsfor well pipe drilling, sealing repair and abandonment processes(killing), Off-center of the access port will include several productionsized ports. The exterior of these ports will include the means tosecure a Pressure Relief/Diversion Valve, Production Valves orProduction Hard Caps. These mounting elements (pins and bolt studs)shall be identical (size, spacing and pattern) on all Production Ports.These ports/valves will be initially opened (as well as the Access Port)during the Dome Assembly (DA) installation (lowering and positioning).The ports/valves are initially used for pressure relief/venting andlatter used for production—or will be capped. The Dome Assembly willinclude numerous standard (non-unique) remotely monitored/controlledequipment such as: Levels, Internal and external closed circuit T.V. (s)and associated lights, Pressure sensors, Oil, water and gas detectorsAll assemblies/adaptors/tools shall include the following whereapplicable: Be made of material capable of withstanding greater thantwice the well's pressure Supporting means compatible with lifting,lowering and positioning the unit from the surface platform and ROV(s)Top and bottom mounting surfaces' compatible (size and shape) with theunits they physically interface with Top and bottom mounting hardware(bolt studs, guide-pins) and compatible (size and pattern) holes andcaptivated securing components with the units they physically interfacewith:

Mounted gaskets compatible with the size and shape of the unit and theunit it physically interface with the means to remotely remove andreplace all internal functional elements by a ROV(s). Remotelycontrollable devices shall be designed using electrical, fiber-optics,mechanical, hydraulic and/or pneumatic means with connections compatiblewith a ROV(s) capability to install/remove. There are many different‘working’ pipe sizes and the expandable seals of the P-WIA will likelynot be capable of handling, therefore different sized P-WIA s′ orinserts must be provided. Varying levels of pressure could be applied tothe P-WIA's seals allowing for a fully opened, to fully a hard sealed,as well as intermediate levels allowing for rotating and vertical pipemovement as well as sequencing the said pressure from the upper & lowerseals as the pipe joints pass thru the unit. Thefunctionally/performance of numerous MFWS unique equipment/tools requireor would be enhanced with the addition of an ‘in-well’ monitoring &control interface. Numerous interface structures could be employed toprovide this function. Although the intent of this document is toprovided a ‘system level’ design the following is provided as designinformation/specifications/requirements for this interface as follows:

Design.

Embedded Fiber-Optic (FO) cable within the drill pipe sidewall,Compression pipe to pipe FO connections, directly connect sensors andcontrolled devices attached to the drill pipe to the said cable. Sensorsand controlled devices not directly attached to the drill pipe interfacevia non-physical contact means of coded Light/IR/RF and/or acousticinterface devices (such as a garage door opener or ‘Easy-Pass’ typedevice). Sensor and controlled devices powered by batteries. Controlleddevices using hydraulics would use battery power to activate (in-well)pumps with initial pressure equalization means. Notes/Requirements: TheFO bandwidth is orders of magnitude greater than required (but providesa convenient bi-directional capability). The sensors will includeaddresses (digital/frequency codes) capable of any future conceivableneed. The following define the minimum required simultaneousfunctionally, which basically defines/limits the requirements of thecontrolling/monitoring unit. 25 discretes—yes/no (such as sensed gas),15 levels indicators with ten to the 5.sup.th dynamic range (such aswell pressure), 15 controls (such as turn on/off), 15 controlstatus/feedback.

The sequence of operations of the Pipe Cutter Mechanism will beinitiated by an operator at the Remote Monitor and Control Unit (RM&CU).In the automatic operational mode, after being ‘initiated’, an embeddedmicro-processor and program in the RM&CU will control and perform thecutting process described below. In a manual mode the operator willperform the steps below: 1. An operator at the RM&CU will initiate apipe cut defining a given size pipe. 2. The Circular Saws and LateralDrive Devices drives, with minimum torque contacts the pipe to confirmthe designated pipe size. If different informs the operator. 3. If thepipe designated is confirmed the proper size, the saw motors are turnedon and laterally driven into the pipe until either the thickness of thepipe-wall is penetrated or the saw motor speed decreases greater than20%. If the latter occurs see * (below). 4. When the pipe-wall ispenetrated, the Turn-Table Motor turns on and continues to cut the pipeuntil either the Turn-Table turns to where the pipe is cut by each saw110 degrees or the saw motor speed decreases greater than 20%. If thelatter occurs see * (below). 5. When three saws have cut the pipe 110degrees, Circular Saws and Lateral Drive Devices retract the saw bladesand: The Turn-Table is positioned at 120 degrees. 6. The Wedges' LateralDrive Devices is activated pressing the wedges into the pipe cut. 7. TheCircular Saws' Lateral Drive Devices is again activated to drive the sawblade towards the pipe until either the thickness of the pipe-wall ispenetrated and the pipe is fully cut or the saw motor speed decreasesgreater than 20%. If the latter occurs see * (below). 8. Once the pipeis fully cut it must be extracted. If another pipe needs to be cut, thefirst pipe must be pulled clear of the pipe cutting lateral drivemechanism.

*If any of the saws speed decreases greater than 20% from its unloadedspeed, the appropriate drives will be backed-off until the no-load speedis obtained. The drives will then proceed to the continuing cuttingprocess.

The heart the pressure relief, diversion, capture and recovery subsystemis the unique seabed containment/separator tank supported with itsprimary interfaces devices (manifold, remote controlled valves andoffset/diversion piping) providing the means to vent and/or captureoil/gas.

This continuation-in-part application incorporates a new capture device(a Containment Balloon) as an additional option to venting into the seaor capturing in a surface containment device (floating opened top-closed sidewall area or tanker(s)).

This continuation-in-part subsystem description further identifiesvarious means (pipe/tank thermal insulation, heaters and/or anti-freezechemical injection) incorporated in the pressure relief, diversion,capture and recovery flow path to guard against potentialfreezing—blocking gases.

The objective of the Intrusion Detection and Response Subsystem (ID&RS)is to protect the surface and underwater oil well elements fromdeliberate human intervention. It is assumed a 3D restrictive zone willbe established about an individual or group of oil wells.

The ID&RS provides the means to detect, track and classify the 3Daspects (bearing, range, and depth) of air/surface/sub-surface objectsabout a specific oil well or group of oil wells. It also provides themeans to evaluate potential threats and ‘Hard and/or Soft Kill’ threats.

The ID&RS elements are identified in four categories as follows:

1. Major existing military type platform equipment that provides shortrange AAW, ASUW and ASW capability including such items as: Radars(search and fire control), IFF, ESM, Sonar, Active and Passive Decoys(Acoustic, RF and IR), Hard Kill Weapons (guns, missiles, torpedoes anddepth charges). 2. Major existing military/commercial type equipmentsuch as: LAMPS Helicopter and ROV s. 3. Unique equipment such as:

Array(s) of sea surface tethered remotely controlled RF and IRgenerators/decoys, Array(s) of below sea tethered remotely monitoredPassive Acoustic Sensors (PAS) and a platform mounted PAS, Remotelycontrolled acoustic generators/decoys and remotely controlled acousticcorner reflectors, Interface, Processing and Display Monitor andControls 4. Trained Operator(s).

Many of the terms such as ‘short range’ and ‘weapons’ are quitesubjective and since the primary threat is considered to be quiterudimentary the following are identified as design guidance: A Radar(search, fire control and integrated IFF) capability such as the MK92CAS, Weapons such as the Standard Missile, Harpoon and Mk46 Torpedoeswould work but have a significant over kill for the anticipated threat,Hard Kill weapons could include such items as a MK15 CIWS, a 3″ gun,SUBROC and Helicopter launched depth charges and shoulder type fire andforget anti-air and anti-surface missiles.

ID&RS Detail Design Notes/Information

The acoustic sensors and arrays are conceptually based on USN ASUW andASW detection and processing techniques. The subsurface piggy-back depthangle sensor and the related arrays depth determination is unique butbased on the triangular processing of the bearing and range. It isanticipated the sensed ‘depth angle’ will be compromised by sea-floorand surface reflections/bounce, but it is assumed that integrating overtime and averaging the three differently located sensors data willprovide tangible results. The tracking, classification, threat analysisand threat response recommendations are also based on USN processing.

The RF, IR and acoustic generators and corner reflector(s), and theirassociated array, are conceptually based on USAF and USN air tacticalcounter-measures (stand-off jammers and gate stealers) and USN submarinecounter-measures (decoys).

The Light Airborne Multi-Purpose System (LAMPS) operations are based onthe USN LAMPS MK111 ASW and ASUW techniques.

The following describe a single well installation utilizing a USN orUSCG Ship for the ‘Major existing military type platform equipment thatprovides short range AAW, ASUW and ASW capability’.

It is assumed alternative interfaces, operations and arrayconfigurations could be derived for well platform based equipment and/ormultiple well implementations.

The Radar and associated IFF and Electromagnet (passive detection)Sensor (EMS) are the ‘eyes’ for above the surface, while the passiveacoustic sensors are the ‘eyes’ for below the surface.

The acoustic sensor array provides subsurface and surface detection dataand the means required to triangulate the sensors detections todetermine Bearing, Range and Depth. The outputs of the acoustic sensors*and control signals for all generators (RF, IR and acoustical) interfacewith (via cable) an Array Distribution Unit (ADU). The ADU(data/controls) interfaces (via cable) with to the Data and SignalFormatter (D&SF). D&/SF on a (oil well) platform digitizes andserializes the signals. The digitized and serialized signal is sent tothe platforms RF Data Link and then the ship's RF Data Link. The data isthen sent to the Processor where is processed for display monitoring anddisplay interface, detection support (bearing, range and depthdetermination for acoustic contacts) and tracking, classification,threat analysis and related recommendations, as well as historicalstorage for air, surface and subsurface contacts.

The processed data and information is then sent to the Display Monitorand Control Unit. A trained Operator views/reviews the data andinformation and determines and initiates appropriate actions.

The processing will include an operator selectable auto threat-quickreaction ‘soft-kill’/decoy mode, allowing the program to automaticallycontrol the RF, IR, acoustical generators and corner reflectors.

The controls are sent to the appropriate selected unit(s) (specificsensor and/or generator) via the Processor, RF Data Link, DataFormatter, Array Distribution Unit and then to the appropriate unit.LAMPS Helicopter interfaces via its own data link.

If ROV actions are required, a stand alone interface, monitor andcontrol system identical to the existing ROV's will be used.

If the Ship has a sonobuoy receiver system compatible with the numberand type of sonobuoys in the array the sensors could directly (via RF)interface with the ship.

It is assumed the sensor (RADAR, IFF, and ESM etc.) and weapons on a USNor USCG Ship identified as short range AAW, ASUW and ASW capable wouldwell serve this mission, particularly as supplemented.

The RF and IR Generators/Decoys are standard simplistic active noise orrepeater source similar to numerous such devices used by the USN andUSAF. The device shall be externally stimulated and controlled by theProcessor to produce outputs capable of:

Being totally silent, Producing broadband continuous wave frequenciesover the entire spectrum of anticipated homing devices, at power levelsgreater than the anticipated homing device's transmitter, Producing acontrolled variable delayed pulsed repeater outputs compatible with thepulse-width and spectrum of an anticipated active pulsed homing device.The controlled variable delay shall have a minimum range from; <1 us togreater than 10 ms. The repeater will further have controlled powerlevels from a maximum equaling the anticipated power of a homingdevice's transmitter, to minimum power level of zero.

The Passive Acoustic Sensor (PAS) is derived from a modification of thestandard AN/SSQ 53 Directional Frequency Analysis and Recording (DIFAR)Sonobuoy.

The low-tech modifications include: Providing an external power sourcevia cable (vs. internal battery power), Removing the antenna outputinterface and utilize output via cable interface format, Mounting twounit's piggy back on different axis (one producing bearing angle and theother depth angle),Increase buoyancy to insure unit with attached cable(and attached Acoustic Generator has significant positive buoyancy.

The Acoustic Generator (AG) is a simplistic active acoustic noise sourcesimilar to numerous such devices used by the USN.

The device shall be externally stimulated and controlled by theProcessor to produce outputs capable of: Being totally silent, Emulatingthe acoustic signature of an oil well's sea-floor and platform, withpower levels equal to ten times the said well, Producing broadbandcontinuous wave acoustic frequencies over the entire spectrum ofanticipated homing devices, at power levels greater than an anticipatedhoming device's transmitter, Producing a controlled variable delayedpulsed repeater output compatible with the pulse-width and spectrum ofan anticipated active pulsed homing device. The controlled variabledelay shall have a minimum range from; less than 10 us to greater than10 ms. The repeater will further have controlled power levels from amaximum equaling the anticipated power of a homing device's transmitter,to a minimum power level of zero. The Acoustic Corner Reflector (ACR) isa simplistic passive decoy type device. It is basically composed of twoflat acoustical reflective crossing plains (crossing in the center) at90 degrees that reflects an acoustical signal back in the same angle itwas received. The ACR further includes a remote controlled element thatrotates (from the center) one of the plains to form a dual flat surface.The ACR is deployed with weighs on the sea-floor and/or tethered atdifferent depths.

The PAS and AG units will be connected (via cable or be physicallyjoined) and typically deployed in functional sets of three or fourtypically @ equal distance from each other and equal distance about aspecific well (or in other functional sets about a group of wells).

Each of the PAS, AG and/or ACR units will be tethered from the sea-floorto pre-determined depths. The RF & IR generators will be tethered to thesea surface.

The said tethered cables could include various combinations ofsensors/decoys. The sea-floor will hold the tethered cable with weightscapable of insuring it does not change its position (depth, lat. andlong.). The cable length from the tethered weight to the sea-floor toplatform shall be the planned distance plus about one and a half timesthe sea depth (for future recovery/maintenance). A single (non-joined)AG will be mounted on the underside of the surface platform providingthe means to calculate (via the processor) the exact position and aspectof the joined PAS and AG devices.

The ROV(s) is identical to such devices used by the oil industry fordeep off-shore drilling but this unit's interface cables will belengthened so it can travel greater than two miles from the platform.The ROV(s) provide the means to view, evaluate and move delayed fusedunder-sea explosives.

The Array Distribution Unit (ADU) function only acts as a convenientphysical wire/cable distribution center.

The Data and Signal Formatter (D&SF) is an active electronic data andsignal formatting device located on the platform.

The ‘formatting includes: Analogue to Digital conversion, Digital toAnalogue conversion, Multiplexing and De-multiplexing into and from asingle serial digital data interface cable. The D& SF will have theminimum through-put capacity (bandwidth) to simultaneously handle: FromSensors: Acoustic outputs of eight type AN/SSQ-53 Sonobuoys. Plus 50%(control, feedback, status, etc.). To Sensors and Generators:Approximately 25% of the ‘from sensors’ bandwidth

It is assumed devices matching/exceeding these requirements areavailable ‘off-the shelf’ (from Industry/US Government). The RF DataLink is a common device used by industry and the government. The deviceconverts serial (cable media) electronic data/signals to RF fortransmission to another location via an antenna and likewise receives RFand converts it to serial electronic data/signals.

The capacity (bandwidth) must be compatible with the requireddata/signals of the system, as identified for the D&SF.

It is assumed devices matching/exceeding these requirements areavailable ‘off-the shelf’ (from Industry/US Government).

*The above assumes a separate in-place ship to helicopter (LAMPS) datalink.

The Processor includes a computer and specialized computer programs. TheProcessor provides critical functions related to thesurface/sub-subsurface objects: Detection, Position, Tracking,Classification, Threat Analysis and related recommendations Theprocessor also provides interface for the Display Monitor and ControlUnit. The processor further provides for sensor position and aspectcalibration, operator training via simulation and historical operationalrecording.

It is assumed the computers are in-place on the ship, or a computermatching/exceeding the required process capacity and speed are available‘off-the shelf’ commercially. The ‘specialized computer programs wouldhave to be developed, but the USN utilizes similar functional softwarefor their AAW, ASUW and ASW mission. If such were made available thedevelopment (time, cost and risk) would be reduced by an order ofmagnitude.

The Display Monitor and Control Unit (DM&CU) provides for the operatorto system interface.

The Light Airborne Multi-Purpose System (LAMPS) is identical to thatused by the USN for surface and sub-surface detection, localization andengagements.

Although specific operational displays, modes, functions or controls arenot specified in detail at this time, it is assumed the DM&CU isin-place on the ship or a unit matching/exceeding the requirements iscommercially available—large touch-screen monitor would well serve theall requirements.

It is understood that the preceding description is given merely by wayof illustration and not in limitation of the invention and that variousmodifications may be made thereto without departing from the spirit ofthe invention as claimed.

1-20. (canceled)
 21. A pressure relief, diversion, capture and recoverysubsystem that provides the means to reduce pressure at the seabeddrilling equipment divert oil/gas from the seabed drilling equipment'slocation to a safe area receive and contain the gas/oil/mud/sea wateroutput of the seabed's drilling equipment, separate these outputs andprovide the means to capture, contain and/or vent the separated outputsin emergency conditions wherein; a three or more port manifold isincorporated on the seabed drilling equipment wherein the primaryfeed-thru ports are connected in series/in-line with the well bore andprovides feed-thru access to a drill pipe and drill bit wherein aparallel/secondary port of a manifold provides external access to theflow of liquids/gases of the well's existing seabed equipment andwherein a remote-controlled valve is connected to thisparallel/secondary port, followed by a pipe extending horizontally alongthe seafloor to a safe location, wherein the other end of the said pipeis connected to an input port of a containment/separator/venting tank onthe seabed, wherein the separator/venting tank incorporates, ballast, aplurality of three vertically separated output ports on the sidewallwherein, each port is connected to an associated remote control valveswherein the separator/venting tank further includes a plurality of oneseawater, mud, gas and/or oil internal sensors and wherein all of theabove said remote control valves and said sensors electrically interfacewith the surface drilling platform.
 22. The pressure relief, diversion,capture and recovery subsystem of claim 21 further incorporating aplurality of one vertical riser pipes extending from theseparator/venting tank to the sea surface.
 23. An inflatable-expandablegas/oil/mud containment balloon device that provides a safe and low-costmeans to capture gas/oil/mud from an offshore oil/gas well wherein athree or more port manifold is incorporated on the seabed drillingequipment wherein the primary feed-thru ports are connected inseries/in-line with the well bore and provides feed-thru access to adrill pipe and drill bit wherein a parallel/secondary port of a manifoldprovides external access to the flow of liquids/gases of the well'sexisting seabed equipment and wherein a remote-controlled valve isconnected to this parallel/secondary wherein an inflatable-expandablegas/oil/mud containment balloon is connected in the liquid/gas/mud flowpath of the secondary/parallel port of the said manifold, wherein theinitially deflated balloon receives pressurized gas/oil/mud—inflates,contains and stores the said gas/oil/mud.
 24. The pressure relief,diversion capture and recovery subsystem of claim 22 that furtherincorporating a gas/oil tanker connected to the output riser pipe. 25.The pressure relief, diversion capture and recovery subsystem of claim22 that further including an expandable gas/oil/mud containment balloonconnected to the output riser pipe.
 26. The pressure relief, diversioncapture and recovery subsystem of claim 21 that further in incorporatingan expandable gas/oil/mud containment balloon(s) connected to thecontainment/separator/venting tank.
 27. The pressure relief, diversioncapture and recovery subsystem of claim 22 that further i incorporatinga floating sea surface opened top-closed sidewall containment deviceconnected to the riser pipe.
 28. The pressure relief, diversion captureand recovery subsystem of claim 21 that further incorporates thermallyinsulated pipes.
 29. The pressure relief, diversion capture and recoverysubsystem of claim 21 that further incorporates thermally insulatedsidewalls on the separator/venting tank.
 30. The pressure relief,diversion capture and recovery subsystem of claim 21 that furtherincorporates warming/heating device/elements within the flow path of thepressure relief, diversion capture and recovery subsystem.
 31. Thepressure relief, diversion capture and recovery subsystem of claim 21that further incorporates an additional secondary/parallel port the saidmanifold wherein a remote controlled valve is connected wherein theother port of the valve is connected to a device capable of injecting ananti-freeze agents into the flow path of the pressure relief, diversioncapture and recovery subsystem.